Day 1 Mon, March 13, 2023最新文献

{"title":"Failure Analysis of PCP Due to Sudden Gas Breakthrough in CBM Well : A Case Study","authors":"S. Rajvanshi, Rajiv Nischal, Bulusu V. R. V Prasad, M. Yadav, Manish Kumar, Devendra Pratap Gaur, Divyansh Sethi","doi":"10.2118/214073-ms","DOIUrl":"https://doi.org/10.2118/214073-ms","url":null,"abstract":"\u0000 Progressing Cavity Pump (PCP) is a well-known artificial lift mode which is widely used for dewatering of coal bed methane (CBM) wells because it has good sand & gas handling capacity and better performance in deviated well in comparison to other rod pumps. However, compatibility of elastomer in downhole condition is always a challenging task for PCP operation. In this study, failure analysis of PCP well # A from ONGC field has been done in detail and suggest suitable remedial measures for multiple challenges.\u0000 In well # A, high torque was observed during dewatering and after that sucker rod unscrewed. During work over it was observed that rotor got stuck up in the stator due to damage of elastomer. Based on reservoir study, it was found that unexpected gas breakthrough occurred from upper coal seam. Pump was placed above the upper coal seam therefore gas directly entered at the pump intake and elastomer got damaged. Another issue was high rod-tubing contact load due to highly deviated profile of the well. One guide per rod configuration was adopted for this well which is not enough to protect rod and tubing where maximum contact load simulated in standard software. The depth of failure of sucker rod is exactly matching with the depth of the maximum rod-tubing contact load.\u0000 Based on two main challenges- high rod-tubing contact load & gas interference, different approaches have given in this study for safe pump operation keeping in view the field constraints.\u0000 For high rod-tubing contact load, conclusions are drawn in this study with respect to important parameters causing significant effect. Suitable type and accurate configuration of rod guides are also suggested in this study.\u0000 For gas interference problem, natural gas anchoring, tail pipe and use of different types of gas anchors have been compared and discussed to mitigate challenges in view of solid fines. Suitable elastomer type is also suggested depending on the well parameters.\u0000 In case of multiple and complex problems observed in the well, this study gives novel idea to increase mean time between failure (MTBF) of PCP for dewatering of CBM wells in a relatively simple and effective manner.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116782613","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Maximizing Recovery and Reducing Well Cost Using Herringbone Multilateral Horizontal Well Drilling and Completion Technology","authors":"Xiaocheng Zhang, Tao Xie, Hongbo Huo, Ruibing He, Hai Lin, Xinxin Hou, Dongsheng Xu","doi":"10.2118/214019-ms","DOIUrl":"https://doi.org/10.2118/214019-ms","url":null,"abstract":"\u0000 With the in-depth development of Bohai Oilfield, China National Offshore Oil Corporation (CNOOC), the water cut of some old wells become too high to produce while nearby remaining recoverable reserves are still considerable. In order to maximize recovery and reduce well construction cost, herringbone multilateral horizontal well drilling and completion technology is employed to increase drainage area of single well and make full use of well slot and old wellbore.\u0000 Considering the current development of oilfield and the geological characteristics of reservoir, the technical difficulties of herringbone multilateral horizontal well drilling and completion technology including high build-up rate, easy blockage of drilling tools in the sidetracking in open hole, easy collapse and instability of sandwich wall and high requirements for drilling fluid performance are analyzed and solved.\u0000 This technology has been successfully applied in three wells with total 6 branches and the production of three wells is twice higher than that of conventional horizontal wells with no water cut, which fully verified the reliability of the branch well tools and the feasibility of the technology.\u0000 Herringbone multilateral horizontal well drilling and completion technology provides a new idea for the treatment of low production and low efficiency wells in a sustainable way and will be widely promoted and applied in Bohai oilfield, which can also provide reference for other high water cut oilfields.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"172 S1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120863802","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pinpointing Source of Sustained High Casing Head Pressure (HCHP) for Well Integrity Restoration: A Case Study of a Well in the Niger Delta","authors":"Arthur Bougha, John Oluleye, Daniel Ivrogbo, N. Okonkwo","doi":"10.2118/214017-ms","DOIUrl":"https://doi.org/10.2118/214017-ms","url":null,"abstract":"\u0000 Maintaining the integrity of oil and gas wells is of utmost importance. This requires regular monitoring to ensure the barrier envelop is maintained. Sustained pressure in the casing infers a compromised barrier envelop. It poses a serious threat to the well integrity and if not addressed could lead to increased risk of pressure transmission and fluid leakage through the concentric tubulars. The key objective is the ability to accurately pinpoint the source of the pressure.\u0000 Modern technologies using through-tubing logging systems are more accurate for leak detection. If the leak is not accurately detected, the sustained high casing head pressure persists and could lead to undesired outcomes even after the repairs. Here, the high accuracy Sonic-Noise Log (SNL-HPT) was deployed through slickline. Data acquisition process involved both shut-in and flowing modes. The shut-in mode required the well to be stable while RIH SNL-HPT tools on slickline for data acquisition. While in the bleed off mode, the well was being produced during data acquisition. A surface choke manifold and flowback tank were rigged-up for flow control.\u0000 In this paper the results of well Unut-4 Sonic Noise Log- High Pressure and Temperature (SNL-HPT) surveys are presented. The objective was to investigate the source of A annulus pressure in this well. The data was successfully acquired in memory via slickline up to a depth of 10,000ftah using both shut-in and bleed off (flowing) modes. The shut-in mode required the well to be stable while RIH SNL-HPT tools on slickline for data acquisition. While in the bleed off mode, the well was being produced during data acquisition. The acquired data was successfully downloaded and interpreted for the source of leak. The SNL-HPT interpreted data indicated that the High CHP was caused by communication observed through leaks at depth 9,751ft (the dual packer). The spectral noise logging located the active leak source and verified the integrity of cement barriers while the High temperature logging quantified the leak rate using temperature modelling. This paper would detail the history of the well, planning, design and execution of the successful logging including the interpreted results.\u0000 Sonic Noise Log is a simple technology to deploy for accurate leak source determination. In all the instances this was deployed, acquired and interpreted data was good enough for a decision making on the forward plan. The results of this logging led to the early injection of the well in the rig sequence and well was subsequently worked over. Integrity was restored with further deferment of production averted.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123748848","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Experimental Study on the Effect of Gas on the Performance of a Multi-parallel Pipe Oil-Water Separator (MPPS)","authors":"H. Asaadian, M. Stanko","doi":"10.2118/214062-ms","DOIUrl":"https://doi.org/10.2118/214062-ms","url":null,"abstract":"\u0000 This work presents a comprehensive experimental study on the effect of gas on the performance of oil-water bulk separation in a multi-parallel pipe separator (MPPS). Several flowrates of gas, up to 10% volume fraction were tested and values of separation efficiency and water cut ratio were estimated from measurements. Also, the three-phase flow pattern upstream the separator inlet is reported.\u0000 Exxsol D60 spiked with 700 ppm of crude oil, 3.4 wt% NaCl saltwater, and air were used in steady-state and transient tests on a transparent 6.1 m long, 15.24 cm diameter, separator prototype. Preliminary values of separation efficiency and water cut ratio were measured over a variety of total flow rates (300 to 700 L/min), water cuts (WC, 30%, 50%, 70%, and 90%), and water extraction rates (ER, 50% to 90% the rate of inlet water)\u0000 It is observed that the gas phase accumulates at higher sections of the separator (i.e. at the inlet section after the splitting and at the exit section where water rich fluid is tapped from the bottom of the pipe). It seems the reduction in separation performance is due to turbulence caused by the gas and reduced cross section for the oil-water mixture to flow. The higher the gas flow rate, the lower the separation efficiency and water cut ratio. The presence of gas impacts more flow conditions with low water cuts including 30 and 50%. The presence of gas has less negative impact on separator performance when the liquid flow rate is high. Results show even small amounts of gas entering the separator have a significant detrimental effect on oil-water separation.\u0000 Pipe oil-water separators have several advantages over heavy gravity vessels, including cost, compactness, ease of deployment and enable energy saving by separating close to the source. However, this study shows that the presence of gas can impact dramatically their performance. Thus, the performance of upstream gas separation must be studied closely.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126815822","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"New Normal at United Energy Pakistan Limited","authors":"S. M. U. Farid","doi":"10.2118/214024-ms","DOIUrl":"https://doi.org/10.2118/214024-ms","url":null,"abstract":"\u0000 The Coronavirus pandemic challenged most industries in ways unimaginable, forcing people to consider a variety of operational models which were previously unthinkable. UEP also adapted a Work-From-Home (WFH) model for its office-based staff to ensure operational continuity. A few months into the Pandemic, discussions at UEP were initiated to determine how the organization intends to manage office resumption once the Pandemic eases.\u0000 A holistic strategy was devised to seek inputs of stake holders, research global and local trends to arrive at an informed decision. The findings indicated that while globally there were discussions around New Normal the local companies were generally not inclined in changing the way they work. UEP also sought feedback on the work-from-home setup from its employees via pulse survey and focus groups. Based on the results and multiple deliberations it was decided to move towards a hybrid model as the New Normal for UEP. A key focus area throughout the process was the impact on employees and the subsequent impact on Talent Management at UEP.\u0000 This paper will discuss the series of events which led to the formalization of the \"New Normal for UEP\" and how it has impacted UEP's Talent Management. The paper will also briefly touch upon the post implementation feedback and lessons learnt from focus groups and highlight areas of improvement to fine tune the working model to what suits UEP best.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"433 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124243011","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Reducing Time Losses in Well Construction Operations by Improving Early Detection through a Digital Operation Integrity Center and Digital Aids","authors":"Abdulqawi Al Fakih, Arnott Dorantes, Carlos Alberto Perez, Gerardo Javier Duque, Mohamed Nabil Dewidar, M. Nafi","doi":"10.2118/214027-ms","DOIUrl":"https://doi.org/10.2118/214027-ms","url":null,"abstract":"\u0000 Optimizing well time and its expenditures have become a necessity for which all drilling operators and service companies are challenged on. This requires a combination of well engineering and operations efforts, from avoiding service quality issues that lead to Non-Productive Time (NPT) to reducing or eliminating Invisible Lost Time (ILT). Traditionally, more focus and efforts are concentrated around NPT avoidance, as its impact is visible and has a huge and direct financial consequence that leads to an impact on well cost. The ILT was left out of focus due to needing proper measurement tools. In turnkey projects, the real-time monitoring concept was adopted to reduce the ILT and, at the same time, the NPT.\u0000 From 2018 to 2022, the time interval selected for this study, nearly 800 wells were drilled with good progressive performance of feet per day (Ft/day) year on year and continuous reduction in NPT impact. The performance was measured on 40,000 days of operating time which was impacted by almost 5,000 days of related non-productive time. The multi-hour loss events were classified according to their root cause, divided into four major categories, hole condition, human decision, tool failure, and other external (i.e., waiting times). This paper will describe the solution for the first two causes categories of time losses.\u0000 During the problem definition process, a common factor was the criticality of having a short response time at the early stages of the events. The evidence showed a direct correlation between the response time and the total lost hours in any event; hence the efforts focused on reducing the time between early detection and execution of corrective actions. Implementing an Operational Integrity Center aimed to standardize the detection of events and establish a central support team that will recognize wrong actions and recommend corrective actions quickly. The Center integrated multiple digital solutions to maximize the accuracy and reliability of predictions.\u0000 The introduction of the digital operation integrity center (DOIC) resulted in a 30% reduction in the global NPT in terms of the number of days up to the end of 2022, considering the increasing operating time. This success is based on three major pillars: process, people, and tools.\u0000 In terms of process, the team established a new set of processes (SOP)to monitor operations and set an iterative do-learn-improve cycle. Those processes have enhanced the workflows of transforming data into insights and delivering these insights to Well Site Leader (WSL), reducing the response time.\u0000 In terms of people, the team was trained in process assurance, digital tools, event detection, stress management, and effective communication; the training focused on reducing the response time after identifying signs of possible events.\u0000 The final pillar was implementing digital tools; the DOIC used monitoring and prediction tools. Monitoring tools are well known and have been used for many years ","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124377204","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Managing High Bottom-Hole Temperature Challenges in Slim Long Horizontal Wells: a Case Study from the Biggest Gas Field in the Middle East","authors":"E. Ovwigho, M. Almomen, Mauricio Corona, Jose Terrez","doi":"10.2118/214047-ms","DOIUrl":"https://doi.org/10.2118/214047-ms","url":null,"abstract":"\u0000 The deep carbonate reservoir formation on this field has proven to be an extreme High-temperature (HT) environment for downhole equipment. While drilling the 5000 − 6500 ft 5-7/8\" slim long laterals across this formation, very high bottom-hole circulating temperatures is encountered (310-340 degF) which exceeds the operating limitation for the downhole drilling/formation evaluation tools. This resulted in multiple temperature-related failures, unplanned trips and long non-productive-time. It became necessary to provide solution to reduce the BHCT-related failures.\u0000 Performed offset-wells-analysis to identify the BHT regime across the field, create a heat-map and correlate/compare actual formation-temperatures with the formation-temperature-gradient provided by the operator (1.4-1.8 degF/100-ft). Drilling reports/MWD/LWD/wireline logs were reviewed/analyzed. Discovered the tools had a maximum-temperature-rating of 300-302 degF and were run outside-technical-limits. Temperature-related-failures were predominant in long slim-laterals, which indicated that some of the heat was generated by high flow rate/RPM and solids in the system. Tried drilling with low-RPM/FR, without meaningful-temperature-reduction. After detailed risk-assessment and analysis on other contributing factors in the drilling process, opted to incorporate mud-chiller into the surface circulating-system to cool-down the drilling mud.\u0000 Upon implementation of the mud chiller system, observed up to 40 degF reduction in surface temperature (i.e. temperature-difference between the mud entering/leaving mud chiller). This was achieved because the unit was set-up to process at least twice the rate that was pumped downhole. Also observed reduction in the bottomhole circulating temperature to below 300 degF, thus ensuring the drilling environment met the tool specifications. The temperature-related tools failure got eliminated. On some of the previous wells, wireline logging tools have been damaged due to high encountered downhole temperature as circulation was not possible prior-to or during logging operation. The implementation of the mud-chiller system has made it possible for innovative logging through-the-bit logging application to be implemented. This allows circulation of cool mud across the entire open hole prior to deployment of tools to perform logging operation. This has made it possible for same logging tool to be used for multiple jobs without fear of tool electronic-components failure die to exposure to extreme temperatures.\u0000 The long non-productive time due to temperature-related tool failures got eliminated. The numerous stuck pipes events due to hole deterioration resulting from multiple round trips also got eliminated. Overall drilling operations became more efficient.\u0000 The paper will describe the drilling challenges, the systematic approach implemented to arrive at optimized solution. It will show how good understanding of drilling challenges and tailored-solutions delive","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"129 2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130056144","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"3D OBN High Resolution Seismic Acquisition Design for Better Sub-Surface Imaging, Cheleken, Caspian Sea","authors":"Aldrin Rondon, Lamia Rouis, M. Khdhaouria, G. Ameish, Liao Xiaoliang","doi":"10.2118/214048-ms","DOIUrl":"https://doi.org/10.2118/214048-ms","url":null,"abstract":"The Cheleken contract Area lies in the Turkmenistan sector of the South Caspian Sea, over an area of 920 Km2 and in water depth of 10 to 40 m. Located in a complex wrench faulted system orientated WNW-ESE from the Apsheron Peninsula in Azerbaijan to the Cheleken Peninsula in Turkmenistan, the cheleken fields have a large thickness of stack sand and shale reservoirs, with significant areal and vertical variation. The presence of strike slip faults, gas Chimney, H2S in some reservoir fluid, and low sweep efficiency due to the aforementioned geological complexities are challenges that need to be addressed. In 2004, the first seismic acquisition campaign was carried out by Dragon Oil in order to get a full dataset of seismic data covering the whole field, the acquisition technology considered for this dataset was Ocean Bottom Cable (OBC) and it was designed to cover the entire stratigraphic column down to deeper sections (approximately 7000 meters), therefore, deep objectives were not properly imaged due to technical limitations at that time. Seismic resolution was compromised and this OBC technology couldn't account for surface obstructions among other technical and logistic limitations. In 2015, Dragon Oil started with the idea to acquire a new seismic dataset with improved technology to aid in the better definition of sub-surface targets and define a more detailed and reliable structural framework as input for the Static and Dynamic Modeling Process. The ultimate goal of acquiring a new seismic dataset considering OBN Technology, was to define an optimal drilling strategy based on a more robust and reliable static and dynamic modeling of the field. Ocean Bottom Node Seismic has emerged as an effective technology for seismic exploration/development in numerous challenging acquisition environments with the key added value of higher data quality and much better seismic imaging. By placing receivers on the seafloor and decoupling the source from these receivers, the recorded data offers high quality imaging through improved multiple suppression and better subsurface illumination, without limitations existing with conventional streamer operations. Full Azimuth, long offset illumination, high fold are characteristics of Ocean Bottom Node (OBN) acquisition technology and it's proven successfully in extremely complex structural/stratigraphic environments and highly obstructed areas. This technology unfolds a wide range of geophysical options to generate a detailed geomodel of the field and also unlocks additional technical studies and seismic analysis.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132147018","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Innovative TCP-ESP Under Balance Perforation Using Hydraulic Packer and Firing Head","authors":"M. Sayed, Napoleone Luca, Shimaa A. Naser, A. Salah, Karim Amr","doi":"10.2118/214001-ms","DOIUrl":"https://doi.org/10.2118/214001-ms","url":null,"abstract":"\u0000 The objective in any perforated completion is to maximize the productivity index in a cost effective manner, which is to increase the flow rate for a given driving force (draw down) or to minimize the draw down for a given rate that could be achieved through minimizing the total well skin effect.\u0000 Underbalance perforation through Tubing Conveyed Perforating (TCP) system is one of the best practices to ensure less damage to the perforation tunnels (perforating skin) leading to increased well productivity. However, it is very challenging in cases of completions using Electrical Submersible Pump's (ESP) to maintain productivity with undamaged reservoir by preventing any contact between reservoir and completion fluid and achieve the above simultaneously with safe well control during ESP deployment. Otherwise, the alternative solution is to perforate over balance using casing guns or run TCP string in single run then kill the well after perforation in order to install the ESP completion meanwhile both alternative ways lead to damage in the perforated tunnels.\u0000 As reducing operating costs is a must, maximizing well productivity, and minimizing wellbore clean-up time, an innovative solution was designed and successfully implemented for perforating artificially lifted wells in static underbalanced condition meanwhile installing ESP completion in single run without killing the well. It combines the use of TCP system containing special hydraulic firing head (delaying technique with orifice and chamber filled with oil) equipped with hydraulic packer with on-off tool. TCP gun string with the hydraulic packer has been run by tubing and set hydraulically against the required intervals, then the ESP has been separately installed and the guns has been activated through a hydraulic firing head for a shoot-and-stay operation. The static underbalance condition has been created by the ESP thanks to the delayed firing time.\u0000 After this operation, the well has been directly lined up to production flow-line with minimal wellbore clean-up time. The combination of static underbalanced perforation with deep penetration charges which is able to bypass invasion zone with depth of penetration more than 65 inch, can create a clean perforation tunnel, and significantly reduce the post-perforating damage by killing fluid, and finally maximize the well productivity. Despite the challenging reservoir conditions (Depth= 10200 FT, Pressure=3850 Psi, Temperature= 28544 deg. F), the Productivity Index (PI) of the wells were three times compared to the offset wells.\u0000 This job has been performed by Agiba Petroleum Company, one of the main operators in Western Desert of Egypt, employing this combined TCP-ESP technique which has resulted in significant savings in cost as well as rig time and increased operating efficiency. This paper summarizes the practical experiences gained during the development and deployment of this integrated technique, in addition to an evaluation of the impact","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114488948","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Well Placement Design for Enhancing Heat Recovery from Geothermal Systems: Sensitivity Analysis using Thermo-Poro-Elastic Effects","authors":"Reda Abdel Azim, G. Hamada","doi":"10.2118/214082-ms","DOIUrl":"https://doi.org/10.2118/214082-ms","url":null,"abstract":"Geothermal energy is considered one of the most promising energy to replace oil and gas. In order to enhance this type of energy from the geothermal reservoirs, an appropriate design and evaluation tool is required to assess the stimulation treatment for improving the reservoir permeability. This paper presents an innovative approach to evaluate the well placement and designed stimulation program under thermo poroelastic coupling process using momentum, mass and energy conservation. The proposed approach is applied on a selected volume of Soultz reservoir to assess the permeability enhancement over stimulation period of more than 3 month and fluid circulation period of 14 years. In this method, the change in fracture is caused by shear slippage. The proposed stimulation model evaluates different scenarios of well placement, hydraulic fracture geometry and injection program with an objective of economic heat recovery using different fracture parameters. Results show that the thermal stress led to decreasing the produced fluid temperature across the reservoir. This is due to the fact that distributed 3-D thermal stress support in increasing the fracture opening which leads to creation of flow channeling between the injectors and producers. In addition, the result show that the presented model is capable of evaluating simulation parameters such as well placement and induced fracture geometry. This has also allowed us reducing the risk of short circulating due to excessive permeability enhancement.","PeriodicalId":286390,"journal":{"name":"Day 1 Mon, March 13, 2023","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114833927","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}